Biorenewable naphtha

ABSTRACT

The present invention generally relates to a method for producing a naphtha product from a renewable feedstock. The method includes hydrotreating the renewable feedstock to produce a hydrotreating unit heavy fraction that includes n-paraffins, and hydrocracking the hydrotreating unit heavy fraction to produce a hydrocracking unit product that includes the naphtha product. The method also includes separating the naphtha fraction and optionally recycling the hydrocracking unit heavy fraction through the hydrocracking unit. The present invention also relates to a biorenewable naphtha product suitable for use as feed stock for steam crackers and catalytic reforming units, and for use as fuel, or fuel blend stock.

CROSS-REFERENCE TO RELATED PATENT APPLICATIONS

This application is a Continuation of U.S. Ser. No. 13/196,768, filed Aug. 2, 2011, which is a Continuation-In-Part of U.S. application Ser. No. 12/132,915, filed Jun. 4, 2008, both of which are incorporated herein by reference, in their entireties, for any and all purposes. This application is also a Continuation-In-Part of U.S. application Ser. No. 13/197,542, filed Aug. 3, 2011, which is a Continuation of U.S. application Ser. No. 12/132,915, filed Jun. 4, 2008, both of which are incorporated herein by reference, in their entireties, for any and all purposes.

FIELD OF THE INVENTION

The present invention generally relates to a method for producing hydrocarbons from biomass. Specifically, the present invention relates to converting naturally occurring triglycerides and fatty acids to a composition including naphtha boiling range hydrocarbons. The present invention also relates to the resultant biorenewable naphtha product, whereby the naphtha is used as chemical feed stock, fuel, fuel blend stock, or solvent.

BACKGROUND OF THE INVENTION

The term “green chemistry” has been used to describe synthesis of chemicals from biorenewable feed stocks. It is considered a sustainable alternative to petroleum-based chemistry, and may mitigate the effect of high oil prices. One of the challenges facing transition to a green chemical industry is that the existing production facilities and infrastructure are designed around hydrocarbon feed stocks. For example, the building blocks of the chemical industry, olefins and BTX aromatics (benzene, toluene, and xylene), are produced in steam crackers (also referred to as ethylene crackers) and catalytic reformers that run on light hydrocarbons. Synthesis gas, or syngas for short, is another chemical building block. Syngas is a mixture of carbon monoxide and hydrogen and can be produced by steam reforming of light hydrocarbons. Naphtha is a C₅-C₉ hydrocarbon cut that is commonly used as the feedstock for both catalytic reformers and steam crackers. It may also be used as feed for steam reforming units for production of syngas.

In particular, paraffinic naphtha is considered a highly desired feed for steam crackers due to its high ethylene and propylene yields. Production of naphtha from biorenewable sources would enable transition to a green chemical industry without the need to develop new chemistries and build new production facilities.

Naphtha is also a common industrial solvent. Extraction of lipids from seeds (e.g. soybean oil) uses n-hexane from petroleum naphtha. However virgin naphtha distilled from crude oil typically contains 2.5% to 5.0% by weight benzene, a well-known carcinogen. As such, multiple and costly purification steps (e.g. solvent extraction and super-fractionation) are required before food-contact quality hexane is obtained.

The term “sustainable energy” has been used to refer to renewable sources of energy. Biorenewable fuels are a key component of sustainable energy initiatives. Naphtha may be used directly as fuel in industrial furnaces or turbines. It may also be used in small industrial engines such as lawnmowers and chainsaws.

Furthermore, since naphtha hydrocarbons are in the motor gasoline boiling range, they may be used as a gasoline blend stock. Gasoline blends need to meet vapor pressure and octane rating requirements.

One method of producing naphtha hydrocarbons from biomass is by the Fischer-Tropsch (F-T) process. U.S. Pat. No. 7,214,720 to Bayle and co-inventors describes a process involving the steps of (a) gasification, (b) syngas purification, (c) F-T conversion, (d) separation, and (e) recycle of at least a portion of the naphtha to gasifier. Although the process produces the desired hydrocarbon naphtha from a bio-renewable source, gasifiers suffer from a low reliability record. Additionally, the capital costs associated with gasification and F-T conversion are known to be very high. This is in part due to solids handling requirements for the gasifier and heat removal provisions for the highly exothermic F-T reaction. Furthermore, the need to recycle part of the naphtha to the gasifier further reduces the efficiency of this process as a source of bio-renewable naphtha.

U.S. Pat. No. 5,186,722 to Cantrell and Chong describes a catalytic process to convert biomass feeds such as limonene to a composition of cyclic and aromatic compounds in the naphtha boiling range. Although these products are reported to have high octane rating and hence good gasoline blend stocks, they lack the desired properties as a chemical feed stock. As feeds for steam crackers, aromatic compounds give low ethylene and propylene yields. More importantly, the terpene feeds used in the process are among the only biomass sources that to begin with are hydrocarbons. Virtually all other sources of biomass have high oxygen content, typically greater than 10 wt %.

Deoxygenation of biomass feeds such as triglycerides and fatty acids are disclosed in U.S. Pat. No. 7,232,935 to Jakkula and co-inventors. A two step process is disclosed which includes hydrodeoxygenation of triglycerides/fatty acids followed by hydroisomerization. The process produces diesel boiling-range isoparaffins.

To this end, there is a need for biorenewable naphtha that can be used as feed stock for existing petrochemical and refining facilities. In particular, the present invention is a method process for converting high oxygen content biomass, such as sources of triglycerides and/or fatty acids, into naphtha boiling-range hydrocarbons using standard refining processes.

SUMMARY OF THE INVENTION

The present invention relates to a method for producing from a biorenewable feed stock a hydrocarbon naphtha composition useful for producing olefins, BTX aromatics, hydrogen, and also for direct use as gasoline blend stock and solvent. The biorenewable feed stock includes sources of glycerides (i.e. monoglycerides, diglycerides, triglycerides, etc.) and/or fatty acids and combinations thereof, such as animal fats, animal oils, poultry fat, poultry oils, vegetable oils, vegetable fats, plant fats and oils, rendered fats, rendered oils, restaurant grease, brown grease, waste industrial frying oils, fish oils, tall oil, and the like and any combinations thereof.

The method for producing hydrocarbon naphtha includes hydrotreating a renewable feedstock to produce a heavy hydrocarbon fraction. This is followed by hydrocracking of the hydrotreated heavy fraction to produce a distribution of hydrocarbon components, typically C₃-C₁₈, which is fractionated to recover the naphtha product. The heavy fraction is optionally recycled to the hydrocracker.

The hydrotreating of triglycerides and fatty acids involves olefin hydrogenation and deoxygenation. Hydrotreating thus converts fatty acids into long chain paraffins as illustrated in Equations 1 and 2 for conversion of oleic acid to n-octadecane and n-heptadecane. HOOC—C₁₇—H₃₃+2H₂ →n-C₁₈H₃₈+2H₂O  (1) HOOC—C₁₇—H₃₃+H₂ →n-C₁₇H₃₆+CO₂  (2)

When the fatty acids are supported on a glycerol backbone, for example as triglycerides or diglycerides, the hydrotreating reactions of Equations 1 and 2 produce propane as well as the long chain, heavy hydrocarbon fraction. Depending on the source of the fatty acid/triglyceride, the heavy hydrocarbon fraction is predominantly in the C₁₂ to C₂₂ range.

The heavy hydrocarbons may be hydrocracked into shorter chain hydrocarbons to produce biorenewable naphtha. In the illustrative hydrocracking reactions of Equations 3-5, n-octadecane is hydrocracked into naphtha-range hydrocarbons, nonanes, hexanes, pentanes, and propane/butanes byproducts. C₁₈H₃₈+H₂ →n-C₉H₂₀ +i-C₉H₂₀  (3) i-C₉H₂₀+H₂ →i-C₅H₁₂ +i-C₄H₁₀  (4) n-C₉H₂₀+H₂ →i-C₆H₁₄+C₃H₈  (5)

The naphtha thus obtained is a biorenewable isoparaffinic composition, free of oxygenates and benzene.

The present invention is directed to a naphtha boiling range hydrocarbon composition derived from a biorenewable feedstock. The biorenewable feedstock having monoglycerides, diglycerides, triglycerides, free fatty acids, and combinations thereof. The biorenewable feedstock is selected from the group including animal fats, animal oils, poultry fat, poultry oil, vegetable fats, vegetable oils, rendered fats, rendered oils, restaurant grease, brown grease, waste industrial frying oils, fish oils, fish fats, and combinations thereof. Broadly, the composition of the present invention includes greater than about 90.0% by weight of total n- and iso-paraffins; and less than about 1.0% by weight of total aromatics. The paraffins include C₄, C₅, C₆, C₇, C₈, C₉, and C₁₀ paraffins. The composition has a boiling range of about 70° F. to about 400° F. The composition has a specific gravity at 20° C. of from about 0.680 to about 0.740. The composition may further include, less than about 0.5% by weight of olefins, less than about 6.5% by weight of naphtenes, and/or less than about 1.0% by weight of total aromatics.

Further, the present invention is directed to a naphtha boiling range hydrocarbon produced from a biorenewable feedstock, wherein the hydrocarbon has a boiling range between about 70° F. and about 400° F.; and a specific gravity at 20° C. of from about 0.680 to about 0.740. The hydrocarbon has greater than about 90% by weight of total n- and iso-paraffins. The hydrocarbon may further include, less than about 0.5% by weight of olefins, less than about 6.5% by weight of naphtenes, and/or less than about 1.0% by weight of total aromatics. The composition and/or hydrocarbon are free of benzene and oxygenates.

The present invention provides a product produced from a biorenewable feedstock. The product includes a naphtha boiling range hydrocarbon having a boiling range between about 70° F. and about 400° F.; and a specific gravity at 20° C. of from about 0.680 to about 0.740, wherein the product is a benzene-free solvent. The hydrocarbon of the product of the present invention may be fractionated into a bio-based hexane product inherently free of benzene.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a schematic diagram of an operation for producing biorenewable naphtha according to the present invention.

FIG. 2 is a schematic diagram of another embodiment of a method for producing biorenewable naphtha in accordance with the present invention.

FIG. 3 is a gas chromatogram showing product from an example.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

The present invention relates to a method for producing from a biorenewable feedstock a hydrocarbon product of naphtha boiling point range that can be used as feedstock for olefins, BTX aromatics, and hydrogen plants. The biorenewable naphtha of the present invention may also be used directly as a fuel, a fuel blend stock, or a solvent.

Referring to the process embodiment of FIG. 1, a biorenewable feed 101 is transferred to a hydrotreater 102 where it reacts with hydrogen under pressure of from about 300 psig to about 3,000 psig, preferably from about 1,000 psig to about 2,000 psig. Feed 101 may optionally be pretreated to remove contaminants. The hydrotreater 102 is preferably a packed bed of sulfided bimetallic catalyst, preferably nickel-molybdenum (NiMo), nickel-tungsten (NM), or cobalt-molybdenum (CoMo) on alumina support. It should be understood by one of ordinary skill in the art that any catalyst may be used in the present invention so long as the catalyst functions in accordance with the present invention as described herein.

To maintain the active metal sulfide functionality of the catalyst despite absence of organic sulfur in most bio-renewable feeds, feed 101 may be supplemented with a sulfur compound that decomposes to hydrogen sulfide when heated and/or contacted with a catalyst. Two preferred sulfur compounds are dimethyl disulfide and carbon disulfide. Preferred concentration of these in the feed 101 is from about 100 to about 2,000 ppm by weight sulfur. Alternatively, feed 101 may include a biorenewable component and a petroleum fraction wherein the petroleum-fraction provides the sulfur.

Feed 101 may be preheated before entering the hydrotreater 102. The hydrotreater 102 operates from about 300° F. to about 900° F., preferably from about 550° F. to about 650° F., and from about 250 psig to about 3,000 psig. In order to reduce the adiabatic temperature rise from the exothermic hydrotreating reactions and to maintain the hydrotreater 102 in the preferred operating range, a number of methods known in the art may be used. These methods include, but are not limited to, feed dilution with a solvent or other diluent, liquid product or solvent recycle, and use of quench zones within the fixed-bed reactor wherein hydrogen is introduced.

The biorenewable feed 101 liquid hourly space velocity through the hydrotreater 102 is from about 0.2 h⁻¹ to about 10 h⁻¹, preferably from about 0.5 h⁻¹ to about 5.0 h⁻¹. The ratio of hydrogen-rich treat gas 110 to biorenewable feed 101 is preferably in the about 2,000 to about 15,000 SCF/bbl range. The hydrogen-rich treat gas 110 may contain from about 70 mol % to about 100 mol % hydrogen.

A hydrotreater effluent 103 includes a deoxygenated heavy hydrotreater fraction and unreacted hydrogen. The hydrotreater effluent 103 may also include water, carbon oxides, ammonia, and hydrogen sulfide. The long chain, heavy hydrocarbon fraction in the liquid phase is separated from the gas phase components in a separation unit 104.

The separation unit 104 includes a high pressure drum (not shown) operated at hydrotreater discharge pressure (about 1,000 psig to about 2,000 psig in the preferred embodiment), wherein long chain, heavy hydrocarbon liquids are separated from hydrogen and gas phase hydrotreater byproducts. It should be understood that the hydrotreater discharge pressure may be operated from about 200 psig to about 3,000 psig. Depending on the temperature of the separation unit 104, water may be in vapor or liquid phase. In a preferred embodiment, the separation unit 104 has a temperature in the about 350° F. to about 500° F. range whereby water, carbon oxides, ammonia, hydrogen sulfide, and propane are removed with hydrogen in a separator drum vapor phase. To enhance removal of the components from the heavy hydrocarbon fraction, the separation unit 104 optionally includes a stripping section (not shown). Water 111 may be condensed, separated, and the hydrogen-rich gas phase 105 recycled to the hydrotreater 102.

A long chain hydrocarbon product stream 112 from the separation unit 104 is then cracked in a hydrocracker 114. Product stream 112 is optionally combined with unconverted heavies from the hydrocracker 114, and recycled stream 125, to form a hydrocracker feed 113.

The heavy hydrocarbon feed 113 cracks in the hydrocracker 114 to form naphtha-range hydrocarbons. Preferably, the hydrocracker 114 operates from about 250 psig to about 3,000 psig, more preferably from about 1,000 psig to about 2,000 psig. Hydrocracker 114 temperatures are from about 400° F. to about 900° F., preferably from about 580° F. to about 750° F. Suitable catalysts for hydrocracking according to the present invention as described herein are bi-functional catalysts with hydrogenation and acidic functionalities. Such catalysts include Group VIII metals on amorphous (e.g. silica-alumina) or crystalline (e.g. zeolite) supports. Preferred hydrocracking catalysts are platinum, palladium or combinations of same on an amorphous silica-alumina support. However, it should be understood that any catalyst may be used in accordance with the present invention as long as it functions as described herein. Preferred ratios of the hydrogen-rich gas to liquid feed for hydrocracking are in the about 1,000 to about 10,000 SCF/bbl range, and liquid hourly space velocity in the about 0.1 h⁻¹ to about 8 h⁻¹ range, preferably from about 0.2 h⁻¹ to about 4 h⁻¹. Stream 115 is an effluent of the hydrocracker 114 wherein un-reacted hydrogen includes a gas phase. Hydrogen-rich gas is separated from the hydrocarbon product in a separation unit 116.

The separation unit 116 includes a high pressure separation drum (not shown), operating at hydrocracker discharge pressure, about 1,000 psig to about 2,000 psig in the preferred embodiment, where hydrocarbon liquids are separated from hydrogen, hydrocarbon vapors, and any other gas phase cracked products. It should be understood that the hydrocracker discharge pressure may be operated from about 200 psig to about 3,000 psig.

A hydrogen-rich gas 117 from the separation unit 116 is combined with a hydrogen-rich gas 105 from the separation unit 104 and optionally processed through an absorption column or scrubber 108 to remove ammonia, carbon oxides, and/or hydrogen sulfide, before recompression for recycle to the hydrotreater 102 and/or hydrocracker 114. Depending on the contaminant to be removed, the scrubber 108 may use various solvents such as amine and caustic solutions. It is clear to those skilled in the art that other gas cleanup technologies may be used instead of or in addition to the scrubber 108 to remove contaminants that affect the hydrotreater 102 and hydrocracker 114 catalyst activity and selectivity. Examples of alternative gas cleanup technologies include membrane systems and adsorbent beds.

A purge stream 107 may be removed from a recycle gas 106 to prevent buildup of contaminants that are not effectively removed in the scrubber 108. The cleaned hydrogen-rich gas 108 a from the scrubber 108 may be combined with makeup hydrogen 109 to form a hydrogen-rich gas stream 110 for the hydrotreater 102 and hydrocracker 114.

Stream 123 is the liquid hydrocarbon phase from the separation unit 116. Stream 123 is processed through fractionator unit 124 to fraction the hydrocracker products into a hydrocarbon vapors product 127, the desired naphtha product 126, and a heavies fraction 125 which is optionally recycled to extinction through the hydrocracker 114.

The fractionator unit 124 is operated to recover biorenewable naphtha, typically with a C₄-C₉ hydrocarbon distribution. Despite the relatively high oxygen content of the biological feedstock, the naphtha product is free of oxygenates. The biorenewable naphtha includes 80% to 100% by weight n- and iso-paraffins. In preferred embodiments of this invention, biorenewable naphtha n- and iso-paraffin content is greater than 90% by weight. The total aromatics content is in the range of 0 to 2% by weight, preferably less than 1% by weight. Cycloparaffins (or naphtenes as they are more commonly known) may also be present in the biorenewable naphtha at up to 7.0% by weight. The olefin content of biorenewable naphtha is less than 0.5% by weight, preferably in the range of 0 to 0.3% by weight.

No benzene is present in the biorenewable naphtha. The biorenewable naphtha product may thus be used as a solvent for food-contact applications. For example, stream 126 may be subjected to conventional distillation for separating the C₆-cut from the C₄-C₁₀ paraffinic hydrocarbon distribution, wherein the C₆-cut is used as bio-based hexane solvent for vegetable oil extraction.

Referring now to FIG. 2, another embodiment of the present invention is illustrated. A biorenewable feed enters a hydrotreater reactor (not shown). Stream 212 is the heavy hydrocarbon product of the hydrotreating reaction in the hydrotreater. Stream 212 is optionally combined with an unconverted heavy fraction 225 to form a hydrocracker feed 213. Hydrocracker feed 213, a C₁₅-C₂₂ hydrocarbon distribution for most common triglycerides and fatty acids, is converted to a C₃-C₁₈ distribution in a hydrocracker 214. An effluent 215 from the hydrocracker 214, is separated into a hydrogen-rich gas stream 217 and a cracked liquids stream 223 in a separation unit 216. Operating conditions are the same as for FIG. 1.

A fraction of the hydrogen-rich gas 217 is purged as stream 207 and the remaining fraction of the hydrogen-rich gas 217 is cleaned up in scrubber 208. The cleaned hydrogen-rich gas 208 a is then combined with makeup hydrogen 209 to form a recycle hydrogen-rich gas as hydrocracker stream 210.

Stream 223, cracked liquids from the separation unit 216, is transferred to a product fractionators unit 224. The illustrative C₃-C₁₈ hydrocracked product is fractioned into a C₃/C₄ gas stream 227, a naphtha product stream 226, a middle distillate stream 228 suitable for use as jet kerosene or diesel, and a heavies recycle stream 225.

The resultant biorenewable naphtha has a boiling point range from about 70° F. to about 400° F. and a specific gravity at 20° C. of from about 0.680 to about 0.740. The naphtha product includes C₄-C₁₀ paraffins that are considered superior feed components for steam crackers, and is also an appropriate feed for conversion to BTX aromatics, and hydrogen production. The naphtha composition is also useful as a solvent in applications where low flash point is not a limitation.

As a fuel or fuel additive, the renewable naphtha provides some benefit as a bio-renewable addition to ethanol in that ethanol typically suffers from low vapor pressures and low energy density. The biorenewable naphtha typically has a Reid Vapor Pressure (RVP)>10 psi and may be blended with ethanol in concentrations of 1-30% to make an entirely renewable gasoline replacement for automobiles that has an improved energy density. The bio-renewable naphtha has low octane ratings (typically less than 40 RON) which is offset by the higher octane of the ethanol fuel which is reported to be in the 129 RON range. Thus, the resulting blend easily meets U.S. performance requirements for vapor pressure and octane rating by utilizing the benefits of both fuels.

An alternate approach for using the biorenewable naphtha of the present invention as described herein as a renewable blend stock for motor gasoline is by isomerization of the C₅/C₆ fraction, which is a standard refinery unit process. The C₅/C₆ fraction of the biorenewable naphtha composition may be isomerized to raise RON and make it suitable for blending with gasoline stocks. Typical isomerized products include 2-methylbutane and 2,3-dimethylbutane, with RON values of 93.5 and 105, respectively.

The biorenewable naphtha is used as fuel for industrial burners, boilers, and turbines and as an industrial solvent.

Due to its paraffinic nature and its high hydrogen-to-carbon ratio, the bio-renewable naphtha may also be used as a hydrogen source or as a fuel cell fuel.

In order to further illustrate the present invention, the following examples are given. However, it is to be understood that the examples are for illustrative purposes, only and are not to be construed as limiting the scope of the subject invention.

EXAMPLES Example 1 Hydrotreating of a Biorenewable Feed Stock

The present example demonstrates how naphtha was made from a renewable feedstock. A 100 cc isothermal tubular reactor was filled with 80 cc of a commercial NiMo catalyst and +70-100 mesh glass beads. The catalyst was sulfided with dimethyl disulfide. The sulfiding procedure included step-wise temperature increase to 650° F. After sulfiding, the reactor was cooled to 400° F.

Next a triglyceride/fatty acid feed was introduced to the isothermal reactor. The reactor was slowly heated to 650° F. to achieve full conversion of the triglyceride/fatty acid feed to n-paraffins. The reactor temperature was further increased to 700° F. to maintain good catalyst activity at 80 cc/hr feed rate (1 LHSV).

The hydrotreater performance with beef tallow as the triglyceride/fatty acid feed is summarized in Table 1. The yield of total products on feed basis exceeds 100% in part due to addition of hydrogen and also due to measurement errors associated with gas phase analysis.

TABLE 1 Hydrotreater Conditions and Conversion Performance. Catalyst Active Metals Sulfided NiMo Support Alumina Reactor Conditions Feed Inedible tallow Temperature (F.) 700 Pressure (psig) 1,200 Gas/Oil Ratio (scf/bbl) 14,000 LHSV 1 Products (wt % feed basis) C1 + C2 1.5 Propane 6.1 Water 5.3 Total Liquid Hydrocarbons 88.2

The gas chromatogram of the liquid hydrocarbon product confirmed that under the hydrotreater conditions of Table 1 the tallow feed was converted C₁₅-C₁₈ n-paraffins with no detectable oxygenates remaining No cracked products (C₁₂—) were detected. FIG. 3 is the chromatogram of the product, showing areas where cracked products and unconverted feed would appear.

Example 2 Hydrocracking of Bio-Derived Heavy Hydrocarbons

The mainly C₁₅-C₁₈ n-paraffin composition obtained from hydrotreating bio-renewable feed stocks was used as feed for a hydrocracking pilot plant. These long chain hydrocarbons were derived via hydrotreating a biorenewable feed in a procedure similar to Example 1. The bio-renewable feed was a blend of chicken fat (45%), brown grease (19%), yellow grease (18%), floatation grease (9%), and miscellaneous waste animal fats from industrial food processing operations (9%). The hydrocracking pilot plant was a prototype of the embodiment of the present invention represented by FIG. 2.

The hydrocracker reactor system was loaded with 4.8 liters of a commercial hydrocracking catalyst. The catalyst was platinum-palladium on amorphous alumina/silica support. The reactor was pressurized to 1,000 psig. After catalyst preconditioning, the temperature was increased again to achieve the desired level of hydrocracking to produce the biorenewable naphtha product. The ratio of hydrogen-rich gas (recycle and makeup) to feed was 3,600-3,800 SCF/bbl.

The pilot plant fractionation system included three distillation columns in series. The first stripped off the light hydrocarbons (“debutanizer”) from the hydrocracker effluent, the second (“naphtha tower”) separated the naphtha overhead, and the third (“recycle tower”) separated a middle distillate cut overhead from the heavy bottoms that were combined with the fresh feed and recycled to the hydrocracker.

Table 2 provides the composition and properties of the hydrotreated hydrocarbon fraction and Table 3 summarizes the operating conditions of the hydrocracker, conversion performance thereof, and product properties therefrom.

TABLE 2 Composition and properties of hydrocracker feed of Example 2^(a) Normal Boiling Example 2 ASTM Component Pt. (° F.) Feed D2887SimDist (° F.) C10 345 ND IBP 345 C11 385 ND  5% 516 C12 421 ND 10% 543 C13 455 ND 20% 549 C14 489  1.55 30% 550 C15 520  1.93 40% 576 C16 549  26.03 50% 599 C17 576  4.86 60% 599 C18 601  64.36 70% 601 C19 626  0.00 80% 601 C20 651  1.27 90% 603 C22 696 ND 95% 604 total paraffins 100.0 FBP 671 ^(a)ND = not detectable

TABLE 3 Hydrocracker Run Conditions, Conversion Performance, and Product Properties^(a) Reactor Conditions Reactor 1 Temp (° F.) 726 Reactor 2 Temp (° F.) 721 Pressure (psig) 1002 Feed Rates Fresh Feed Wt (g/hr) 2241.0 Fresh Feed Vol (cc/hr) 2817.5 Recycle Feed Wt (g/hr) 807.6 Recycle Feed Vol (cc/hr) 1026 Total Feed Vol (cc/hr) 3843 LHSV 0.794 Gas Rates H₂ Makeup (scf/hr) 24.5 Inlet Gas (scf/hr) 102.2 Bleed Gas (scf/hr) 15.5 Product Rates C3/C4 (g/hr) Non-condensed C5-C6+ (g/hr) Naphtha (g/hr) 561.3 Middle Distillate Ovhd (g/hr) 1536.5 Naphtha Yields Non-condensed C5-C6 (wt %)  3.3% Condensed naphtha (wt %)  25.0% Total naphtha (wt %)  28.3% Material Balance Closure 100.1% Naphtha Tower Temps Reboiler Liquid 336 Column Skin 409 Column Top 293 Preheater 303 Recycle Tower Temps Reboiler Liquid 564 Column Skin 534 Column Top 492 Preheater 499 Recycle heavies spec. grav. 0.787 Naphtha Properties Specific Gravity 0.705 D2887 SimDist (° F.) IBP 70  5 91 10 135 20 159 30 194 40 211 50 244 60 260 70 290 80 318 90 358 95 387 FBP 432 Middle Distillate Properties API 51.5 Specific Gravity 0.773 Freeze Point (o C.) −39.5 Cloud Point (° C.) −43.0 Flash Point (° F.) 126 D2887 SimDist (° F.) IBP 226  5 291 10 330 20 374 30 412 40 446 50 479 60 510 70 526 80 544 90 565 95 575 FBP 593 ^(a) NM = not measured

Example 3 Bio-Renewable Naphtha as Blendstock for 100% Renewable E-85 Gasoline

Fuel grade bio-ethanol was purchased from Abengoa Bioenergy (Chesterfield, Mo.). The biorenewable naphtha was produced using the Conditions of Examples 1 and 2 with the feedstock of Example 2. Using these blendstocks, an 85 vol % ethanol blend with the bio-renewable naphtha was prepared. Test aliquots of this 100% renewable E-85 gasoline were taken according to ASTM D 2699 and ASTM D 2700 test methods, and Research and Motor Octane Numbers (RON and MON) were measured. The results are summarized in Table 4.

TABLE 4 Octane Rating of 100% Renewable E-85 Gasoline Test Method Test Description Results ASTM D 2699 RON 101.6 ASTM D 2700 MON 89.6 Anti-knock Index (R + M)/2 95.6

The results of Table 4 indicate that the bio-renewable naphtha composition of this invention is well-suited for producing a high octane, 100% renewable gasoline, containing virtually no aromatic hydrocarbons.

Example 4 Steam Cracking of Bio-Renewable Naphtha

A pilot plant steam cracker designed to model performance of commercial units (Van Geem, K. M.; Reyniers, M.-F.; Marin G. B. AIChE J., 50, 173-183, 2004) was used for this experiment. The experiments were conducted using the biorenewable naphtha composition of this invention produced according to the method of Examples 1 and 2. The steam cracker coil outlet pressure was controlled at 1.7 bar, with steam-to-hydrocarbon ratio of 0.45 w/w. The yields of the bio-derived olefins for selected coil outlet temperature (COT) experiments are presented in Table 5. Also included in Table 5 is comparable data for petroleum distillates of similar boiling range.

TABLE 5 Product yields from steam cracking of biorenewable naphtha and petroleum feedstocks of similar boiling range Medium Biorenewable Biorenewable Range Atm. naphtha − naphtha − Petroleum Gas oil COT = COT = Feedstock Naphtha^((a)) (petroleum)^((a)) 1,562° F. 1,535° F. Cracking yield Hydrogen 17.17 12.1 17.32 16.03 and methane Ethylene 34.0 25.9 30.92 30.13 Propylene 15.7 16.2 17.59 18.94 Butadiene 4.7 4.6 5.165 5.282 Total C₄ ⁻ 76.4 63.6 84.04 85.0 products Pyrolysis 18.8 18.4 14.79 14.65 gasoline Pyrolysis 4.8 18.0 0.436 0.359 fuel oil Total 100.0 100.0 99.3 100.0 ^((a))Petroleum steam cracking data from Grub J. and Loser, E. Ullmann's Encyclopedia of Industrial Chemistry, John Wiley; 2005.

As observed in Table 5, the biorenewable naphtha cracks more completely to light olefins than do petroleum feedstocks (higher C₄-products and lower pyrolysis liquids). Yields of the main olefins (ethylene, propylene, and butadiene) are also generally similar or better than petroleum feeds of similar boiling range.

Example 5 Composition of Renewable Naphtha

A sample of the naphtha boiling range product produced in Example 2 was submitted for detailed characterization via GC×GC. This analytical technique, also referred to as “two dimensional GC,” is used for quantitative analysis of complex mixtures. The technique uses two chromatography columns—with a modulator in between—to separate the components based on volatility (x-axis) and polarity (y-axis), thus generating a two-dimensional map of the product composition. As such, compounds with similar volatility but slightly different polarity can be quantified independently (e.g. pentane and methyl-cyclobutane, both having a 36° C. boiling point).

TABLE 6 Composition (wt %) of Bio-Renewable Naphtha Produced in Example 2. Naphtene Carbon Iso- (Cyclo- Number Paraffin Paraffin Olefin paraffin) Aromatic Sum 3 0.172 0.000 0.000 0.000 0.000 0.172 4 1.506 0.963 0.000 0.000 0.000 2.468 5 4.584 4.956 0.000 0.000 0.000 9.540 6 7.784 9.946 0.000 1.055 0.000 18.784 7 7.964 12.870 0.000 1.389 0.108 22.331 8 5.598 11.140 0.022 1.708 0.305 18.773 9 3.249 10.745 0.255 1.708 0.331 16.289 10 1.237 6.519 0.061 0.622 0.089 8.528 11 0.251 2.172 0.000 0.046 0.000 2.469 12 0.062 0.581 0.000 0.000 0.000 0.644 SUM 32.407 59.893 0.338 6.528 0.833 100

The GC×GC analysis, summarized in Table 6, confirms that the renewable naphtha product of the instant invention is paraffinic, with total of only 0.338 wt % olefins and 0.833 wt % aromatics. Furthermore, no benzene (0.00% C.sub.6 aromatics) was observed. Absence of carcinogenic benzene and very low aromatics content makes this biorenewable composition inherently less toxic than petroleum-based naphtha.

Example 6

A naphtha distillate was produced via hydrotreating of beef tallow according to the process of the instant invention. The naphtha distillate was submitted for analysis at a certified ASTM testing laboratory. The measured properties are summarized in Tables 7a and 7b below.

TABLE 7a PIONA and oxygenates analysis of biorenewable naphtha (wt %) Carbon Iso- No. Paraffins Paraffins Olefins Naphtenes Aromatics Oxygenates Total 3 0.882 0.000 0.000 0.000 0.000 0.000 0.882 4 1.207 0.962 0.000 0.000 0.000 0.000 2.169 5 4.242 5.985 0.000 0.050 0.000 0.000 10.277 6 6.867 11.773 0.000 0.784 0.000 0.000 19.423 7 6.629 14.537 0.000 1.629 0.000 0.000 22.795 8 5.457 14.673 0.000 2.364 0.344 0.000 22.838 9 3.518 12.691 0.000 0.693 0.714 0.000 17.616 10 0.412 3.588 0.000 0.000 0.000 0.000 4.000 Total 29.214 64.209 0.000 5.519 1.058 0.000 100.0

TABLE 7b Physical properties of renewable naphtha Property Test Result Relative Density 0.683 Reid Vapor Pressure (psi) at 100° F. 7.606 Calculated Octane Number 58.06 Boiling Range (° F.) IBP −43.67 10 vol % 96.91 50 vol % 200.25 90 vol % 291.61 FBP 345.47 Percent Carbon 84.04 Percent Hydrogen 15.96 Nitrogen (wppm) Below detection (<0.3) Chloride (wppm) Below detection (<1)   H2S content (wppm) Below detection (<1)  

Thus, there has been shown and described a method for producing a biorenewable naphtha product that fulfills all objectives and advantages sought therefore. While presently preferred embodiments of the invention have been described for purposes of this disclosure, it will be understood that numerous changes may be made which will readily suggest themselves to those skilled in the art and which are accomplished within the spirit of the invention disclosed and claimed herein. From the above description, it is clear that the present invention is well adapted to carry out the objects and to obtain the advantages mentioned herein as well as those inherent in the invention. While presently preferred embodiments of the invention have been described for purposes of this disclosure, it will be understood that numerous changes may be made which will readily suggest themselves to those skilled in the art and which are accomplished within the spirit of the invention disclosed and claimed. 

What is claimed is:
 1. A composition comprising at least 80% by weight paraffins, wherein the paraffins mainly fall within the C₁₅-C₁₈ range; aromatics; cycloparaffins; and olefins; wherein: the paraffins, aromatics, cycloparaffins, and olefins are produced by hydrotreating a biorenewable feedstock; and the composition has no detectable oxygenates as determined by gas chromatograph.
 2. The composition of claim 1, wherein the boiling point range is from about 70° F. to about 400° F.
 3. The composition of claim 1, wherein the hydrotreating comprises hydrodeoxygenation.
 4. The composition of claim 1, wherein the composition is a middle distillate fraction.
 5. The composition of claim 1, wherein the biorenewable feedstock is selected from monoglycerides, diglycerides, triglycerides, fatty acids, or a combination of any two or more thereof.
 6. The composition of claim 1, wherein the biorenewable feedstock is selected from animal fats, animal oils, poultry fat, poultry oil, plant fats and oils, vegetable fats, vegetable oils, rendered fats, rendered oils, restaurant grease, brown grease, yellow grease, floatation grease, waste industrial frying oils, fish oils, tall oil or a combination of any two or more thereof.
 7. A diesel fuel comprising the composition of claim
 1. 8. A diesel fuel comprising the composition of claim
 2. 9. A diesel fuel comprising the composition of claim
 3. 10. A diesel fuel comprising the composition of claim
 4. 11. A diesel fuel comprising the composition of claim
 5. 12. A diesel fuel comprising the composition of claim
 6. 13. The composition of claim 1, wherein the composition has less than about 0.5% by weight of olefins.
 14. The composition of claim 1, wherein the composition has less than about 0.3% by weight olefins.
 15. A diesel fuel comprising the composition of claim
 13. 16. A diesel fuel comprising the composition of claim
 14. 